Distribution model responsive to asset identification

ABSTRACT

Models of a distribution network grid are automatically updated in response to real-time location data of uniquely identified temporary devices. Current geographical coordinates are determined within a distance tolerance that is selected as a function of a type of device indicated by the identity indicia. The geographical information system model is updated with a location of a unique identity of the device at the determined current geographical coordinates within the distance tolerance if unique identity of the device not already present within the geographical information system model, or if it is present and a displacement distance from the determined current geographical coordinates of the temporary device to existing geographic coordinates that are stored in the geographical information system model in association with the unique device identity exceeds a specified distance margin.

FIELD OF THE INVENTION

The present invention relates to the design and management of electricalpower distribution systems in response to the identification oftemporary distribution component installations and associatedinfrastructure revisions.

BACKGROUND

Utilities and other large-scale electrical energy providers generallyrely on a number of automated systems and tools to efficiently andsafely distribute electricity over distribution grids. GeographicalInformation Systems (GIS) and Asset Management Systems (AMS) are used tomodel the location of power system equipment and the networkconnectivity. Supervisory Control And Data Acquisition (SCADA) systems,Distribution Management Systems (DMS) and Outage Management Systems(OMS), Customer Information Systems (CIS), Interactive Voice ResponseSystems (IVRS), Information Storage & Retrieval (ISR) system,Communication (COM) Servers, Front-End Processors (FEPs) and FieldRemote Terminal Units (FRTUs) are typically used by supervisorypersonnel to monitor and control in real-time the electrical grid asmodeled by the GIS/AMS.

Generally, DMS, OMS and SCADA components present information withrespect to performance of utility distribution grid structures indelivering electrical power to end users in centralized consoles oroffices in an integrated manner. Such centralized structures generallyrequire the design and maintenance and consideration of detailedcomponent and connectivity models and schematics by service personnel inorder to ensure safe and reliable electrical power delivery. Maintainingsuch models to accurately represent the grid components actuallydeployed and in use with large-scale grids in a timely and effectivemanner presents a number of challenges to effective and efficient use ofutility personnel.

BRIEF SUMMARY

In one aspect of the present invention, a method for automaticallyupdating modeling of a distribution network grid in response toreal-time location data of uniquely identified temporary devicesincludes acquiring identity indicia for a temporary device that isinstalled within an electrical distribution grid. The distribution gridis modeled by a geographical information system of a utility thatprovides electricity to end users through components of the distributiongrid. The method comprehends determining current geographicalcoordinates within a distance tolerance that is selected as a functionof a type of device indicated by the identity indicia. The geographicalinformation system model is updated with a location of a unique identityof the device at the determined current geographical coordinates withinthe distance tolerance if unique identity of the device is not alreadypresent within the geographical information system model, or if it ispresent and a displacement distance from the determined currentgeographical coordinates of the temporary device to existing geographiccoordinates that are stored in the geographical information system modelin association with the unique device identity exceeds a specifieddistance margin.

In another aspect, a system has a processing unit, computer readablememory and a tangible computer-readable storage medium with programinstructions, wherein the processing unit, when executing the storedprogram instructions, acquires identity indicia for a temporary devicethat is installed within an electrical distribution grid. Thedistribution grid is modeled by a geographical information system of autility that provides electricity to end users through components of thedistribution grid. The processing unit also determines currentgeographical coordinates within a distance tolerance that is selected asa function of a type of device indicated by the identity indicia. Thegeographical information system model is updated by the processing unitwith a location of a unique identity of the device at the determinedcurrent geographical coordinates within the distance tolerance if theunique device identity is not already present within the geographicalinformation system model, or if it is present and a displacementdistance from the determined current geographical coordinates of thetemporary device to existing geographic coordinates that are stored inthe geographical information system model in association with the uniquedevice identity exceeds a specified distance margin.

In another aspect, a computer program product for automatically updatingmodeling of a distribution network grid in response to real-timelocation data of uniquely identified temporary devices has a tangiblecomputer-readable storage medium with computer readable program codeembodied therewith, the computer readable program code comprisinginstructions that, when executed by a computer processing unit, causethe computer processing unit to acquire identity indicia for a temporarydevice that is installed within an electrical distribution grid. Thedistribution grid is modeled by a geographical information system of autility that provides electricity to end users through components of thedistribution grid. The processing unit also determines currentgeographical coordinates within a distance tolerance that is selected asa function of a type of device indicated by the identity indicia. Thegeographical information system model is updated by the processing unitwith a location of a unique identity of the device at the determinedcurrent geographical coordinates within the distance tolerance if theunique device identity is not already present within the geographicalinformation system model, or if it is present and a displacementdistance from the determined current geographical coordinates of thetemporary device to existing geographic coordinates that are stored inthe geographical information system model in association with the uniquedevice identity exceeds a specified distance margin.

BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS

These and other features of this invention will be more readilyunderstood from the following detailed description of the variousaspects of the invention taken in conjunction with the accompanyingdrawings in which:

FIG. 1 is a flow chart illustration of a method, system or processaccording to the present invention for automatically updating modelingof a distribution network grid in response to real-time, preciselocation data of uniquely identified temporary devices deployed withinthe grid.

FIG. 2 is a block diagram illustration of a mobile device according tothe present invention in communication with grid distribution andutility components.

FIG. 3 is a flow chart illustration of one aspect of the method, systemor process of FIG. 1.

FIG. 4 is a block diagram illustration of a computer systemimplementation of an aspect of the present invention.

The drawings are not necessarily to scale. The drawings are merelyschematic representations, not intended to portray specific parametersof the invention. The drawings are intended to depict only typicalaspects, examples and embodiments of the invention, and therefore shouldnot be considered as limiting the scope of the invention. In thedrawings, like numbering represents like elements.

DETAILED DESCRIPTION

Geographical Information Systems (GIS) generally provide a system ofrecords used by SCADA, DMS and OMS components to generate a real-timeoperational electrical model of a distribution network or grid for autility or other electricity provider. Distribution networks may beclassified as radial or interconnected networks. A radial network haslong power lines serving isolated load areas by distributing electricityfrom a single, central power supply point or station through the networkarea without connection to any other supply, and is typically found inrural settings with low population and consumer endpoint densities.

Interconnected networks are generally found in more urban areas or otherareas with higher consumer endpoint densities and have multipleconnections to multiple, independent power supply points. The points ofconnection are normally open, but various and different configurationsof the grid may be achieved by selectively closing and opening theswitches, in order to provide a wide variety of power supply profiles toeach of different power consumer endpoints. Operation of interconnectednetwork grid switches may be by remote control from a control center, orthrough direct, manual operation on-site by a lineman or other servicepersonnel. In the event of a fault or required maintenance, a small areaof an interconnected model network can be isolated, wherein theremainder may be kept on supply.

Long electrical supply lines, or feeders, experience voltage drops overtheir length from the supply point to an endpoint. Capacitors andvoltage regulators may be installed at various points along the longfeeders to prevent such voltage drop characteristics to reduce the powerdelivered to consumers at various endpoints served by the feeders, tothereby assure delivery of specified or minimum required levels andquality of electricity to the respective service endpoints.

The characteristics of the supply given to and required by endpointcustomers are mandated by contract between the supplier and customer, aswell as by standards and regulations enforced by utility regulators, forexample as provided by International Electrotechnical Commission (IEC)Standard No. 61968, which defines standards for information exchangesbetween electrical distribution system applications. Variables of thesupply contemplated by such agreements and standards, include type ofelectricity, namely Alternating Current (AC) or Direct Current (DC);nominal voltage specifications and associated tolerances (for example,within plus or minus 5 percent of the nominal voltage specification);frequency, including 50 or 60 Hertz (Hz) for typical consumers, 16.6 Hzand 25 Hz for some electric railways, and 25 Hz for some industrial andmining end users; phase configuration (single-phase and poly-phase,including two-phase and three-phase); maximum demand that will besatisfied (for example, measured as the largest mean power deliveredwithin a specified time period); load factor, expressed as a ratio ofaverage load-to-peak load over a period of time and indicative of adegree of effective utilization of equipment of a distribution line orsystem; power factor of connected load; earthing system specifications,which define the electrical potential of conductors of the distributionnetwork relative to the Earth's conductive surfaces (ground);prospective short circuit current; and maximum level and frequency ofoccurrence of transients.

The distribution networks are often considered the primary focus of gridchanges. They offer all the required functional services to electricitydistributors to and from customers, as well as the services to managedistributed energy resources, including energy storage, plug-in electricvehicles, etc. However, the accuracy and reliability of theimplementation in real-time of systems and tools discussed above inmaintaining the distribution networks is highly dependent on the dataprecision and quality of the GIS data.

More particularly, large systems may experience a large number oftemporary configuration modifications and equipment changes, oftenexperiencing multiple changes on a daily basis from service personnelactions taken to change network configurations to isolate faults,restore services, or perform maintenance. Modifications include cuts,jumpers, temporary switches, and grounds applied at various points in anetwork by field crews, and they should be reflected in the networkoperations model in order to maintain the correct network topology.

With regard to temporary asset modifications in an electrical grid, acut refers to a temporary break of one or more phases, and it may begenerally placed on any type of line. Jumpers are temporary switchconnections between parts of feeder backbones or laterals, and are usedto provide a means of energizing laterals or portions of feeders thathave been isolated because of faults or maintenance. When combined withcuts, jumpers may allow a large variety of types of temporary networkmodifications to be accurately modeled. Phase jumpers connect a jumperfrom phase to phase on a single line.

Temporary modifications also include grounds placed on de energizedsections of a line. Mobile Substations are pre-defined substations thatcan be placed anywhere in the distribution grid, and are generallyconnected to the network by the use of a jumper. Mobile Generators aredistributed energy resources that can be connected temporarily to thedistribution grid to provide power to customers suffering from anoutage, and these are also generally connected to the network by the useof a jumper.

Accounting for the impact of such temporary changes presents a number ofchallenges. In some implementations, about 10% of distribution networkfeeders modeled within a grid must be updated every day due toconfiguration changes or modification of power system equipmentcomponents and line connections. Accordingly, a new model must bebrought online on a regular basis in order to distribution dispatchersto operate the grid within expected and required specifications, whichincreases the level of effort needed to maintain and implement GISmodels so that they are not discordant with the actual, modeledelectrical network.

FIG. 1 illustrates a method, system or process for automaticallyupdating modeling of a distribution network grid in response toreal-time, precise location data of uniquely identified temporarydevices deployed within the grid. At 102 a Global Positioning Satellite(GPS)-enabled mobile programmable device executing a mobile applicationsubmits a unique user credential to an identity management component ofa utility grid via a network communication. The unique user credentialis unique to and identifies and distinguishes both the mobile device andthe technician operating the device from other devices and technicians,respectively. At 104 the utility grid identity management componentchecks the credential against mobile device and technician records (forexample, via comparison to information technology department records,employee records kept within an Identity Management System (IDM), etc.).

If the credential is not within the records, and not otherwise verifiedor validated as associated with an authorized device and operatingtechnician at 106, then the process ends at 108. Else, if the credentialis verified or validated as actively registered and valid within thecompared records, then at 110 the mobile device is authorized to captureidentity and geographic location information for a temporary asset thatis installed into a distribution gird and provide said capturedinformation to an enterprise Asset Management System (AMS) incommunication with or incorporated within a GIS of a utility system.Capturing asset identity characteristics includes scanning unique itembar code identifications that provide information about the asset. Ifbar code data is missing or not available, then the asset may beidentified by model information or otherwise looked up by the AMS innetwork communication with the authorized mobile device, therebyproviding the technician specific item information that includes voltagecarrying characteristics of the item, for example impedance and voltageloss values, etc. The technician may also use the mobile device tocommunicate type and other identity indicia to a utility operationscenter for manual look-up and retrieval of the information at theoperations center and provision of the material in reply to thetechnician operating the mobile device.

At 112 the mobile device scans or otherwise acquires identity indiciafor a temporary asset that is installed within the modeled grid, and at114 activates GPS capability and determines the current geographicalco-ordinates of the temporary device within a precision distancetolerance that is selected as a function of a type of device indicatedby the identity indicia. In some aspects determining the currentgeographical co-ordinates at 114 includes determining currentthree-dimensional (3-D) geographical co-ordinates (horizontal (latitudeand longitude) and vertical (altitude)) of the temporary device withinthe precision distance tolerance.

At 116, in response to receiving the identity indicia and the currentgeographical co-ordinates for the temporary asset from the mobiledevice, a GIS component of the utility updates the grid model with thegeographical coordinates of the identified temporary asset if the assetis new and not already existing within the grid model (the uniqueidentity of the device indicated by the identity indicia is not presentwithin the geographical information system model); or if the assetexists within the model but has moved relative to the coordinatesreflected in a current GIS model record for the asset beyond a specifiedmargin distance (the unique identity of the device indicated by theidentity indicia is present within the geographical information systemmodel and that the determined current geographical coordinates of thetemporary device differ by a specified distance margin from existinggeographic coordinates that are stored in the geographical informationsystem model in association with the unique device identity).

At 118 the mobile device sends, in real-time, the geographicalcoordinates (longitude, latitude, and altitude) of the identifiedtemporary asset within the specified precision to real-time systems ofthe utility that are responsible to monitor and control the networktopology of distribution grid, including SCADA, DMS and OMS components.At 120 the SCADA, DMS and OMS components use the real-time geographicalcoordinates of the identified temporary asset provided by the mobiledevice and the GIS model as updated or not at 116 to update theirreal-time operational model and underlying visualization of distributiongrid and accordingly perform their respective functions in support ofthe utility.

FIG. 2 illustrates an implementation of the present invention wherein amobile device 202 when authorized (for example, at 110 of FIG. 1)acquires identity indicia for a temporary device or asset 204 that isdeployed within a power supply grid 206. The mobile device 202determines the geographic coordinates of the asset 204 within thespecified precision, and provides the asset identity indicia andacquired coordinates to a Mobile Work Force Management Front End System210 of a utility 208 that is supplying power to endpoint customers byuse of the grid 206. The Work Force Management Front End System 210updates geographic asset coordinates for the temporary asset 204 withinthe GIS/AMS component 212 of the utility 208. In response, the GIS 212updates a model of the grid model (if the asset is new or has movedbeyond the specified margin) and provides the updated model to a SCADA214, DMS 216 and OMS 218 of the utility 208, which each update their ownmodels responsively. The Work Force Management Front End System 210 alsodirectly provides on-line, real-time updates of the captured assetinformation of the temporary asset 204, including the determinedgeographical coordinates, to each of the SCADA 214, DMS 216 and OMS 218.

More particularly, the GIS 212 revises the grid model (at 116) toaccount for any change in quality of electrical energy delivery by thegrid that is caused by the determined location of the identifiedtemporary asset 204. At 118 the SCADA 214, DMS 216 and OMS 218 considerthe impact of the identified temporary assets as a function of theirrespective coordinates determined by the mobile device 202 on the powerdelivery characteristics of the grid modeled as updated (or not) by theGIS 212. In one aspect, this process thereby accurately determines theimpedance impact of an identified jumper, or the effect of a new oradditional amount of power supplied by a temporary power supply asset,wherein the impact of the temporary asset 204 may be dependent on ageographic distance of the temporary asset from power supply inputs orconsumer endpoints.

The precision distance tolerance at 114 and the specified margin at 116are selected and applied as relevant to determining an energy deliveryperformance characteristic of the temporary asset or device type,wherein a reported location that varies by more than the precisiondistance tolerance or specified margin would change a value of theenergy delivery performance characteristic of the device type. In oneexample, a jumper line temporary asset installed into a feeder of a gridhas higher impedance per foot (ft., or 0.3 meters) of linear length ofthe jumper than an impedance value per linear foot length of theoriginal feeder line. Therefore, insertion of the jumper into the gridwill have an impedance impact on the modeled grid that varies by lengthof the jumper in feet. Accordingly, in recognition that the temporaryasset type is a jumper, the precision distance tolerance selected andapplied at 114, and the specified margin selected and applied at 116,are each one foot, selected in response to the jumper impedance having avalue defined per foot of linear length. Thus, the location of thejumper along the feeder may be determined within a foot of an actualinstallation point or termination point in any of the three coordinatedirections (latitude, longitude and altitude), and movement or thejumper by more than one foot of displacement in any of these threedirections will trigger a revised GIS model at 116. An insertionconnection point commences an insertion of the jumper into the feederthat begins a bypass of a portion of the original feeder line withrespect to the flow of electricity to a consumer endpoint through thefeeder, and the termination point terminates the jumper back into thefeeder (or other component of the grid) with respect to the flow ofelectricity so that the flow resumes as modeled in the grid (within themodeled impedance and voltage drop parameters, etc.).

If the device identity indicia indicates a length in feet of the jumper,then only one of the insertion and termination points needs bedetermined and identified, and the exact location and length of thejumper within the modeled grid may be determined by the mobile device,GIS, SCADA, DMS or OMS as a function of the known length of the jumper,as prior to the termination point by said length, or after the insertionpoint by said length. For example, the current temporary assetgeographical coordinates may be determined as the geographicalcoordinates of the jumper insertion point, the length of the jumperdetermined from the model of the jumper associated with the temporaryasset identity indicia, the grid model updated to substitute the jumperfor a portion of the feeder line from the current temporary assetgeographical coordinates toward an endpoint consumer over the determinedlength of the jumper.

If the length of the jumper is not known by the identity indicia, or isnot ascertained and manually entered by the technician, then each of theinsertion and termination points may be entered by the technician viathe mobile device and the mobile device, GIS, SCADA, DMS or OMScomponents may determine the jumper length at 114 as a function of adifference in displacement distance between entered geographic locationsof the respective points. For example, determining a beginning set ofgeographical coordinates of a first end of the jumper that is insertedinto the feeder at the insertion point that commences a bypass of thefeeder by electricity flowing through the feeder to an endpointconsumer, and a termination set of geographical coordinates of the other(second) end of the jumper that is inserted into the feeder at thetermination point that ends the bypass of the feeder by the flowingelectricity, which now flows out of the jumper and back into the feederand onward through the feeder to the endpoint consumer. Thus, the lengthof the jumper may be determined as the displacement distance between thegeographical coordinates of the respective end (insertion) points of thejumper.

In another example, the temporary device 204 scanned and located at 112and 114 is a mobile substation connected to the grid 206 via a jumper.If varying the physical location of the mobile substation by less thanthree hundred feet does not impact grid modeling by the GIS, or impactapplication of an updated model by the SCADA, DMS or OMS components,then the precision distance tolerance selected at 114 as relevant todetermining an energy delivery performance characteristic of the mobilesubstation is three hundred feet. However, as noted above, a jumperconnecting the mobile substation to the feeder may have differingimpacts based on one foot increments, and therefore a jumper connectingthe mobile substation to a feeder may be located within a one footprecision, which also indirectly imparts a one-foot precision to thelocation of the mobile substation at the point of connection to thejumper.

FIG. 3 illustrates one aspect of the decision to update the GIS model at116. In response to the data sent by mobile device, at 302 the AssetManagement System (AMS) queries the GIS system for location informationof the identified asset, and if found at 304 returns the asset ID,description and location back to the user-operated mobile device at 306.If the asset is not found at 304, then a separate exception use case isinitiated at 308. The user then verifies at 310 whether the returnedasset description and location retrieved from GIS system, or the newexception use case initiated at 308, and the current location determinedfrom GPS data correctly apply to the temporary asset underconsideration. If not, then an error condition occurs and the processends at 312. However, if the user verifies the data at 310 and the twolocations of the current GPS acquisition and the previous found recordsare different and outside of the pre-defined margin, then the userinitiates the update to the system model by the GIS at 314.

In some aspects, analytics engines generate a variety of reports fromdata generated during the processes described above, for exampleproviding a list of updated locations of assets along with requiredaudit traceability (who updated it, when, etc.).

Aspects of the present invention provide for real-time feeding andupdating of the location geographical co-ordinates of regular electricalassets (i.e., transformer, capacitor, pole, feeder, etc.) as well astemporary assets such as jumpers, cuts in line, etc., to a GIS databasevia the use of mobile devices. Utility companies generally employ alarge mobile workforce to perform planned and unplanned maintenancetasks on power system equipment items that are responsible fortransmitting electricity from a transmission network to loads orcustomers. By providing each worker a mobile device according to thepresent invention this resource can be readily leverage into improvedGIS modeling and other automated component task performances.

Network Connectivity Analysis (NCA) with regard to a distributionnetwork usually covers a large geographic area and must also beresponsive to the different power or voltage levels required bydifferent customers. NCA is an operator-specific functionality whichhelps an operator to identify or locate a preferred network or componentand provide a display of the feed points of various network loads. Aprevailing network topology or grid model may be determined based on thestatus of all the switching devices such as Circuit Breakers (CB), RingMain Units (RMU) and/or isolators that affect the topology of themodeled network. The NCA further assists the operator to know theoperating state of the distribution network indicating radial mode,loops and parallels in the network.

Locating required sources and loads on a large GIS/Operator interface isoften very difficult. Panning and zooming mechanisms provided within aconventional SCADA system Graphical User Interface (GUI) often fail toadequately identify components within a grid to a degree of accuracyneeded to model and cover operational requirements. More particularly,conventional panning and zooming mechanisms are generally limited torecognize longitude and latitude coordinates. By incorporating altitudeinformation as well, aspects of the present invention enablethree-dimensional (3-D) geospatial visualization and modeling of thedistribution of grid within GUI application and mechanisms, as well asprovide enhanced grind component distinguishing capabilities.

For example, a given utility pole used within a grid may carry severaldifferent distribution lines and associated breakers or capacitors. Anoperator viewing a conventional geographical display may not be able todistinguish and select the correct line or device on the pole that isincorporating a temporary device based solely on the longitude andlatitude coordinates of the utility pole reported by a field technician.In contrast, aspects of the present invention determine (at 114 ofFIG. 1) 3-D coordinates of a device detected or scanned, etc., which areused to create or update 3-D geographical models of the grid within theGIS, SCADA, DMS and/or OMS systems (at 116 and/or 120) within aprecision distance tolerance at 114 and a specified margin at 116 thatare selected to distinguish grid elements incorporating the temporaryassets from other grid elements location in close proximity.

More particularly, aspects enable an operator or GIS, SCADA, DMS and/orOMS systems to (automatically) distinguish (for example, at 304 of FIG.3) between and select a correct one of pluralities of lines and devicesthat share common values of two of the determined longitude, latitudeand altitude coordinates determined for a temporary device (at 114, FIG.1). For example, two power lines strung between the same two utilitypoles in parallel and above one another vertically would share the samelatitude and longitude coordinates, but are distinguished by havingdifferent altitude (vertical) locations along the height of the poles,and the difference between their vertical/altitude coordinates willreflect a vertical spacing distance between the lines that is greaterthan the precision distance tolerance specified and applied at 114 andthe margin specified and applied at 116. Two other power lines strungbetween the same two utility poles in parallel but next to each other atcommon altitude (or vertical orientation or height) will share the samealtitude coordinates over their respective lengths strung upon andbetween the poles, but wherein their horizontal coordinates (one or bothof the latitude and longitude coordinates) of the respective lines willvary over the same lengths, and the difference between their horizontalcoordinates will reflect a horizontal spacing distance between the linesgreater than the precision distance tolerance specified and applied at114 and the margin specified and applied at 116. Said differences aretherefore used by aspects of the present invention to correctly identifythe line incorporating the scanned/detected temporary asset from theother line.

More particularly, the precision distance tolerance applied at 114, 116,118 and 120 of FIG. 1 is selected to be less than a physicaldisplacement difference between grid components within horizontal andvertical planes. Only one of a plurality of different lines and devicesmodeled in the grid will share each of the 3-D coordinates (latitude,longitude and altitude) determined for the temporary device, or havecoordinates that are proximate within said precision distance tolerance,signifying to the operator or GIS, SCADA, DMS and/or OMS systems thatsaid grid element incorporates the temporary asset.

The determined coordinates may also be used to infer a 3-D viewapplicable to areas within and outside the substation fences and othergrid area boundaries, in effect for schematic and geographical displaysof a distribution grid and its surrounding areas. Generally, allexisting and possible isolation and earthing (grounding) points onnetwork power lines and circuits must be also included and considered indetermining the grid model. Aspects of the present invention enable gridmodeling revisions in real-time in response to temporary deviceimplementation, and enable SCADA, DMS and OMS to verify in real-timethat the grid may continue to provide power as agreed to an endpoint, inresponse to each new revision to the infrastructure caused by thepresence of newly-detected temporary devices.

Rather than rely upon formal notice from a technician that a jumper hasbeen placed in order to recalculate power distribution parameters,management of the grid according to the present invention automaticallyrecognizes that a jumper has been deployed via receiving an input of atype of jumper (serial code) along with GPS coordinates in real-timefrom the mobile devices described above. Thus, utility systems areenabled to infer that a jumper has been placed by correlating thereal-time GPS coordinate data with the known GPS locations of feederlines, assuming that the feeder now has a jumper temporally installed,and recalculating the impedance, etc., of the feeder line based on thereal-time GPS and device information which indicates the length of thejumper and its distance from a source and end node with precision.Conversely, removal of the temporary jumper may also be automaticallydetected as directly indicated by new, real-time asset temporary datathat shows the absence of the temporary asset formerly detected, withoutthe necessity of relying on manual, human-generated technician workorder entries. Such auto-detection capabilities are particularly usefulin large-scale grid structures, since a large number of devices may beinstalled or removed at any one time, sometimes simultaneously atdifferent locations within the grid. System performance cannot bereliably inferred from observations alone without knowledge (in thereal-time) of data indicating and confirming temporary asset removalsand installation, otherwise the cause of certain performance observationwill not be truly ascertainable. Aspects of the present invention enablea technician to work backwards from knowing the device ID and specificlocation of a given temporary asset to accurately determine any neededchanges to the distribution system parameters to provide power at anendpoint as required/specified.

As will be appreciated by one skilled in the art, aspects of the presentinvention may be embodied as a system, method or computer programproduct. Accordingly, aspects of the present invention may take the formof an entirely hardware embodiment, an entirely software embodiment(including firmware, resident software, micro-code, etc.) or anembodiment combining software and hardware aspects that may allgenerally be referred to herein as a “circuit,” “module” or “system.”Furthermore, aspects of the present invention may take the form of acomputer program product embodied in one or more computer readablemedium(s) having computer readable program code embodied thereon.

Any combination of one or more computer readable medium(s) may beutilized. The computer readable medium may be a computer readable signalmedium or a computer readable storage medium. A computer readablestorage medium excludes transitory, propagation or carrier wave signalsor subject matter and includes an electronic, magnetic, optical orsemiconductor system, apparatus, or device, or any suitable combinationof the foregoing. More specific examples (a non-exhaustive list) of thecomputer readable storage medium would include the following: a portablecomputer diskette, a hard disk, a random access memory (RAM), aread-only memory (ROM), an erasable programmable read-only memory (EPROMor Flash memory), a portable compact disc read-only memory (CD-ROM), anoptical storage device, a magnetic storage device, or any suitablecombination of the foregoing. In the context of this document, acomputer readable storage medium may be any tangible medium that doesnot propagate but can contain or store a program for use by or inconnection with an instruction execution system, apparatus, or device.

A computer readable signal medium may include a propagated data signalwith computer readable program code embodied therein, for example, in abaseband or as part of a carrier wave. Such a propagated signal may takeany of a variety of forms, including, but not limited to,electro-magnetic or optical forms or any suitable combination thereof. Acomputer readable signal medium may be any computer readable medium thatis not a computer readable storage medium and that can communicate,propagate, or transport a program for use by or in connection with aninstruction execution system, apparatus, or device.

Program code embodied on a computer readable medium may be transmittedusing any appropriate medium, including, but not limited to, wireless,wire line, optical fiber cable, RF, etc., or any suitable combination ofthe foregoing.

Computer program code for carrying out operations for aspects of thepresent invention may be written in any combination of one or moreprogramming languages, including an object oriented programming languagesuch as Java, Smalltalk, C++ or the like and conventional proceduralprogramming languages, such as the “C” programming language or similarprogramming languages. The program code may execute entirely on theuser's computer, partly on the user's computer, as a stand-alonesoftware package, partly on the user's computer and partly on a remotecomputer or entirely on the remote computer or server. In the latterscenario, the remote computer may be connected to the user's computerthrough any type of network, including a local area network (LAN) or awide area network (WAN), or the connection may be made to an externalcomputer (for example, through the Internet using an Internet ServiceProvider).

Aspects of the present invention are described above with reference toflowchart illustrations and/or block diagrams of methods, apparatus(systems) and computer program products. It will be understood that eachblock of the flowchart illustrations and/or block diagrams, andcombinations of blocks in the flowchart illustrations and/or blockdiagrams, can be implemented by computer program instructions. Thesecomputer program instructions may be provided to a processor of ageneral purpose computer, special purpose computer, or otherprogrammable data processing apparatus to produce a machine, such thatthe instructions, which execute via the processor of the computer orother programmable data processing apparatus, create means forimplementing the functions/acts specified in the flowchart and/or blockdiagram block or blocks.

These computer program instructions may also be stored in a computerreadable medium that can direct a computer, other programmable dataprocessing apparatus, or other devices to function in a particularmanner, such that the instructions stored in the computer readablemedium produce an article of manufacture including instructions whichimplement the function/act specified in the flowchart and/or blockdiagram block or blocks.

The computer program instructions may also be loaded onto a computer,other programmable data processing apparatus, or other devices to causea series of operational steps to be performed on the computer, otherprogrammable apparatus or other devices to produce a computerimplemented process such that the instructions which execute on thecomputer or other programmable apparatus provide processes forimplementing the functions/acts specified in the flowchart and/or blockdiagram block or blocks.

Referring now to FIG. 4, an exemplary computerized implementation of anaspect of the present invention includes a computer system or othermobile programmable device 522 in communication 520 with one or moretemporary assets 526 (jumpers, mobile substations, phase jumpers,temporary grounds, etc.) that are deployed within a distribution grid.The mobile device 522 scans or otherwise retrieves identity indicia fromor relevant to the temporary assets 526, and determines their geographiclocation coordinate data with a precision relevant to the impact of thetemporary assets 526 on the grid, as described above with respect toFIGS. 1 through 3. Instructions 542 reside within computer readable codein a computer readable memory 516, or in a computer readable storagesystem 532, or other tangible computer readable storage medium 534 thatis accessed by a Central Processing Unit (CPU) 538 of a computer systemor infrastructure 523 of the mobile device 522. Thus, the instructions,when implemented by the processing unit 538, cause the processing unit538 to automatically retrieve and provide temporary asset 526 identityand precise geographic locations in real-time as described above withrespect to FIGS. 1 through 3.

In one aspect, the present invention may also perform process steps ofthe invention on a subscription, advertising, and/or fee basis. That is,a service provider could offer to integrate computer-readable programcode into the computer system 522 to enable the computer system 522 toautomatically retrieve, organize and display multiple-faceted results inresponse to a text string query as described above with respect to FIGS.1 and 2. The service provider can create, maintain, and support, etc., acomputer infrastructure, such as the computer system 522, networkenvironment 520, or parts thereof, that perform the process steps of theinvention for one or more customers. In return, the service provider canreceive payment from the customer(s) under a subscription and/or feeagreement and/or the service provider can receive payment from the saleof advertising content to one or more third parties. Services mayinclude one or more of: (1) installing program code on a computingdevice, such as the computer device 522, from a tangiblecomputer-readable medium device 532 or 534; (2) adding one or morecomputing devices to a computer infrastructure; and (3) incorporatingand/or modifying one or more existing systems of the computerinfrastructure to enable the computer infrastructure to perform theprocess steps of the invention.

The terminology used herein is for describing particular aspects onlyand is not intended to be limiting of the invention. As used herein, thesingular forms “a”, “an” and “the” are intended to include the pluralforms as well, unless the context clearly indicates otherwise. It willbe further understood that the terms “include” and “including” when usedin this specification, specify the presence of stated features,integers, steps, operations, elements, and/or components, but do notpreclude the presence or addition of one or more other features,integers, steps, operations, elements, components, and/or groupsthereof. Certain examples and elements described in the presentspecification, including in the claims and as illustrated in thefigures, may be distinguished or otherwise identified from others byunique adjectives (e.g. a “first” element distinguished from another“second” or “third” of a plurality of elements, a “primary”distinguished from a “secondary” one or “another” item, etc.) Suchidentifying adjectives are generally used to reduce confusion oruncertainty, and are not to be construed to limit the claims to anyspecific illustrated element or embodiment, or to imply any precedence,ordering or ranking of any claim elements, limitations or process steps.

The corresponding structures, materials, acts, and equivalents of allmeans or step plus function elements in the claims below are intended toinclude any structure, material, or act for performing the function incombination with other claimed elements as specifically claimed. Thedescription of the present invention has been presented for purposes ofillustration and description, but is not intended to be exhaustive orlimited to the invention in the form disclosed. Many modifications andvariations will be apparent to those of ordinary skill in the artwithout departing from the scope and spirit of the invention. The aspectwas chosen and described in order to best explain the principles of theinvention and the practical application, and to enable others ofordinary skill in the art to understand the invention for variousembodiments with various modifications as are suited to the particularuse contemplated.

The flowchart and block diagrams in the figures illustrate thearchitecture, functionality, and operation of possible implementationsof systems, methods and computer program products according to variousaspects of the present invention. In this regard, each block in theflowchart or block diagrams may represent a module, segment, or portionof code, which includes one or more executable instructions forimplementing the specified logical function(s). It should also be notedthat, in some alternative implementations, the functions noted in theblock may occur out of the order noted in the figures. For example, twoblocks shown in succession may, in fact, be executed substantiallyconcurrently, or the blocks may sometimes be executed in the reverseorder, depending upon the functionality involved. It will also be notedthat each block of the block diagrams and/or flowchart illustration, andcombinations of blocks in the block diagrams and/or flowchartillustration, can be implemented by special purpose hardware-basedsystems that perform the specified functions or acts, or combinations ofspecial purpose hardware and computer instructions.

What is claimed is:
 1. A method for automatically updating modeling of adistribution network grid in response to real-time location data ofuniquely identified jumpers, the method comprising: acquiring identityindicia for a jumper that is inserted into a feeder line at an insertionpoint within an electrical distribution grid, wherein the electricaldistribution grid is modeled by a geographical information system modelof a utility that provides electricity to end users through componentsof the electrical distribution grid, wherein the jumper has a jumperimpedance value per foot of linear length, wherein the feeder has afeeder impedance value per foot of linear length, and wherein the jumperis inserted between parts of a feeder or connecting a first phase to asecond phase on a single line; determining current geographicalcoordinates of the jumper within a distance tolerance that is selectedas one foot in response to determining that the jumper impedance valuediffers from the feeder impedance value; determining if a uniqueidentity of the jumper that is indicated by the identity indicia ispresent within the geographical information system model; updating thegeographical information system model with a location of the uniqueidentity of the jumper at the determined current geographicalcoordinates of the jumper within the distance tolerance in response to adetermination selected from the group consisting of that the uniqueidentity of the jumper is not present within the geographicalinformation system model, and that a displacement distance from thedetermined current geographical coordinates of the jumper to existinggeographic coordinates that are stored in the geographical informationsystem model in association with the unique device identity exceeds thedistance tolerance; providing the updated geographical informationsystem model to an entity that is selected from the group consisting ofa supervisory control and data acquisition system of the utility, adistribution management system of the utility, and an outage managementsystem of the utility; and providing in real-time the determined currentgeographical coordinates of the jumper within the distance tolerance tothe entity; and wherein the entity monitors and controls a networktopology of the electrical distribution grid in real-time as a functionof the provided updated geographical information system model and thedetermined current geographical coordinates of the jumper provided inreal-time within the distance tolerance.
 2. The method of claim 1,further comprising: integrating computer-readable program code into amobile programmable device; wherein the mobile programmable devicecomprises a processing unit, a computer readable memory and a computerreadable storage medium, and wherein the computer readable program codeis embodied on the computer readable storage medium and comprisesinstructions that, when executed by the processing unit via the computerreadable memory, cause the processing unit to perform the acquiring theidentity indicia for the jumper, the determining the currentgeographical coordinates of the jumper, the determining if the uniqueidentity of the jumper is present within the geographical informationsystem model, the updating the geographical information system modelwith the location of the unique identity of the device at determinedcurrent geographical coordinates of the jumper within the distancetolerance, the providing the updated geographical information systemmodel to the entity and the providing in real-time the determinedcurrent geographical coordinates of the jumper within the distancetolerance to the entity.
 3. The method of claim 1, wherein thegeographical coordinates are three-dimensional coordinates comprising alatitude coordinate, a longitude coordinate and an altitude value; andwherein the step of updating the geographical information system modelwith the location of the unique identity of the device at the determinedcurrent geographical three-dimensional coordinates of the jumper withinthe distance tolerance comprises selecting one of two power lines thatshare common values of no more than two of current geographicalthree-dimensional longitude, latitude and altitude coordinatesdetermined for the jumper within the distance tolerance as a power lineincorporating the jumper, in response to a determining a commonality ofvalues of each of a three-dimensional longitude, latitude and altitudecoordinates for the selected one of the two power lines within thedistance tolerance; and wherein the distance tolerance is less than avertical or horizontal spacing distance between the two lines that isdefined by a difference in corresponding values of the two power linesfor at least one of the three-dimensional longitude, latitude andaltitude coordinates that are determined for each of the two powerlines.
 4. The method of claim 1, further comprising: determining thecurrent geographical coordinates of the jumper as the geographicalcoordinates of the jumper insertion point; determining a specificationlength of the jumper from a model specified in the identity indicia; andupdating the geographical information system model of the electricaldistribution grid to substitute the jumper for a portion of the feederline from the current geographical coordinates of the jumper toward anendpoint consumer over the determined specification length of thejumper.
 5. The method of claim 1, further comprising: determining abeginning set of geographical coordinates of a first end of the jumperthat is inserted into the feeder at the insertion point that commences abypass of the feeder by electricity flowing through the feeder to anendpoint consumer; determining a termination set of geographicalcoordinates of a second, other end of the jumper that is inserted intothe feeder at the termination point that ends the bypass of the feederby the electricity flowing through the feeder to the endpoint consumer;determining a displacement length of the jumper from a displacementdistance between the beginning set of geographical coordinates of thefirst end of the jumper and the termination set of geographicalcoordinates of the second, other end of the jumper; and updating thegeographical information system model of the electrical distributiongrid to substitute the jumper for a portion of the feeder line from thebeginning set of geographical coordinates of the first end of the jumpertoward an endpoint consumer over the determined displacement length ofthe jumper.
 6. A system, comprising: a processing unit in communicationwith a computer readable memory and a computer-readable storage medium;wherein the processing unit, when executing program instructions storedon the computer-readable storage medium via the computer readablememory: acquires identity indicia for a jumper that is inserted into afeeder line at an insertion point within an electrical distribution gridthat is modeled by a geographical information system model of a utilitythat provides electricity to end users through components of theelectrical distribution grid, wherein the jumper has a jumper impedancevalue per foot of linear length, wherein the feeder has a feederimpedance value per foot of linear length, and wherein the jumper isinserted between parts of a feeder or connecting a first phase to asecond phase on a single line; determines current geographicalcoordinates of the jumper within a distance tolerance that is selectedas one foot in response to determining that the jumper impedance valuediffers from the feeder impedance value; determines if a unique identityof the jumper that is indicated by the identity indicia is presentwithin the geographical information system model; updates thegeographical information system model with a location of the uniqueidentity of the jumper at the determined current geographicalcoordinates of the jumper within the distance tolerance, in response toa determination selected from the group consisting of that the uniqueidentity of the device is not present within the geographicalinformation system model, and that a displacement distance from thedetermined current geographical coordinates of the jumper to existinggeographic coordinates that are stored in the geographical informationsystem model in association with the unique device identity that exceedsthe distance tolerance; provides the updated geographical informationsystem model to an entity that is selected from the group consisting ofa supervisory control and data acquisition system of the utility, adistribution management system of the utility, and an outage managementsystem of the utility; and provides in real-time the determined currentgeographical coordinates of the jumper within the distance tolerance tothe entity; and wherein the entity monitors and controls a networktopology of the electrical distribution grid in real-time as a functionof the provided updated geographical information system model and thedetermined current geographical coordinates of the jumper provided inreal-time within the distance tolerance.
 7. The system of claim 6,wherein the geographical coordinates are three-dimensional coordinatescomprising a latitude coordinate, a longitude coordinate and an altitudevalue; wherein the processing unit when executing the programinstructions stored on the computer-readable storage medium via thecomputer readable memory updates the geographical information systemmodel with the location of the unique identity of the device at thedetermined current geographical three-dimensional coordinates of thejumper within the distance tolerance by selecting one of two power linesthat share common values of no more than two of current geographicalthree-dimensional longitude, latitude and altitude coordinatesdetermined for the jumper within the distance tolerance as a power lineincorporating the jumper, in response to a determining a commonality ofvalues of each of a three-dimensional longitude, latitude and altitudecoordinates for the selected one of the two power lines within thedistance tolerance; and wherein the distance tolerance is less than avertical or horizontal spacing distance between the two lines that isdefined by a difference in corresponding values of the two power linesfor at least one of the three-dimensional longitude, latitude andaltitude coordinates that are determined for each of the two powerlines.
 8. The system of claim 6, wherein the processing unit, whenexecuting the program instructions stored on the computer-readablestorage medium via the computer readable memory: determines the currentgeographical coordinates of the jumper as the geographical coordinatesof the jumper insertion point; determines a specification length of thejumper from a model specified in the identity indicia; and updates thegeographical information system model of the electrical distributiongrid to substitute the jumper for a portion of the feeder line from thecurrent geographical coordinates of the jumper toward an endpointconsumer over a determined specification length of the jumper.
 9. Thesystem of claim 6, wherein the processing unit, when executing theprogram instructions stored on the computer-readable storage medium viathe computer readable memory: determines a beginning set of geographicalcoordinates of a first end of the jumper that is inserted into thefeeder at the insertion point that commences a bypass of the feeder byelectricity flowing through the feeder to an endpoint consumer;determines a termination set of geographical coordinates of a second,other end of the jumper that is inserted into the feeder at thetermination point that ends the bypass of the feeder by the electricityflowing through the feeder to an endpoint consumer; determines adisplacement length of the jumper from a displacement distance betweenthe beginning set of geographical coordinates of the first end of thejumper and the termination set of geographical coordinates of thesecond, other end of the jumper; and updates the geographicalinformation system model of the electrical distribution grid tosubstitute the jumper for a portion of a feeder line from the beginningset of geographical coordinates of the first end of the jumper toward anendpoint consumer over the determined displacement length of the jumper.10. A computer program product for automatically updating modeling of adistribution network grid in response to real-time, precise locationdata of uniquely identified jumpers deployed within the distributionnetwork grid, the computer program product comprising: a computerreadable storage medium having computer readable program code embodiedtherewith, the computer readable program code comprising instructionsthat, when executed by a computer processing unit, cause the computerprocessing unit to: acquire identity indicia for a jumper that isinserted into a feeder line at an insertion point within an electricaldistribution grid that is modeled by a geographical information systemmodel of a utility that provides electricity to end users throughcomponents of the electrical distribution grid, wherein the jumper has ajumper impedance value per foot of linear length, wherein the feeder hasa feeder impedance value per foot of linear length, and wherein thejumper is inserted between parts of a feeder or connecting a first phaseto a second phase on a single line; determine current geographicalcoordinates of the jumper within a distance tolerance that is selectedas one foot in response to determining that the jumper impedance valuediffers from the feeder impedance value; determine if a unique identityof the jumper that is indicated by the identity indicia is presentwithin the geographical information system model; update thegeographical information system model with a location of a uniqueidentity of the jumper at the determined current geographicalcoordinates of the jumper within the distance tolerance, in response todetermining at least one of that the unique identity of the device isnot present within geographical information system model, and that adisplacement distance from a determined current geographical coordinatesof the jumper to existing geographic coordinates that are stored in thegeographical information system model in association with a uniquedevice identity that exceeds the distance tolerance; provide the updatedgeographical information system model to an entity that is selected fromthe group consisting of a supervisory control and data acquisitionsystem of the utility, a distribution management system of the utility,and an outage management system of the utility; and provide in real-timethe determined current geographical coordinates of the jumper within thedistance tolerance to the entity; and wherein the entity monitors andcontrols a network topology of the electrical distribution grid inreal-time as a function of the provided updated geographical informationsystem model and the determined current geographical coordinates of thejumper provided in real-time within the distance tolerance.
 11. Thecomputer program product of claim 10, wherein the geographicalcoordinates are three-dimensional coordinates comprising a latitudecoordinate, a longitude coordinate and an altitude value; wherein thecomputer readable program code instructions, when executed by thecomputer processing unit, further cause the computer processing unit toupdate the geographical information system model with the location ofthe unique identity of the device at the determined current geographicalthree-dimensional coordinates of the jumper within the distancetolerance by selecting one of two power lines that share common valuesof no more than two of current geographical three-dimensional longitude,latitude and altitude coordinates determined for the jumper within thedistance tolerance as a power line incorporating the jumper, in responseto a determining a commonality of values of each of a three-dimensionallongitude, latitude and altitude coordinates for the selected one of thetwo power lines within the distance tolerance; and wherein the distancetolerance is less than a vertical or horizontal spacing distance betweenthe two lines that is defined by a difference in corresponding values ofthe two power lines for at least one of the three-dimensional longitude,latitude and altitude coordinates that are determined for each of thetwo power lines.
 12. The computer program product of claim 10, whereinthe computer readable program code instructions, when executed by thecomputer processing unit, further cause the computer processing unit to:determine the current geographical coordinates of the jumper as thegeographical coordinates of the jumper insertion point; determine aspecification length of the jumper from a model specified in theidentity indicia; and update the geographical information system modelof the electrical distribution grid to substitute the jumper for aportion of the feeder line from the current temporary asset geographicalcoordinates of the jumper toward an endpoint consumer over thedetermined specification length of the jumper.
 13. The computer programproduct of claim 10, wherein the computer readable program codeinstructions, when executed by the computer processing unit, furthercause the computer processing unit to: determine a beginning set ofgeographical coordinates of a first end of the jumper that is insertedinto the feeder at the insertion point that commences a bypass of thefeeder by electricity flowing through the feeder to an endpointconsumer; determine a termination set of geographical coordinates of asecond, other end of the jumper that is inserted into the feeder at atermination point that ends the bypass of the feeder by the electricityflowing through the feeder to the endpoint consumer; determine adisplacement length of the jumper from a displacement distance betweenthe beginning set of geographical coordinates of the first end of thejumper and the termination set of geographical coordinates of thesecond, other end of the jumper; and update the geographical informationsystem model of the electrical distribution grid to substitute thejumper for a portion of the feeder line from the beginning set ofgeographical coordinates of the first end of the jumper toward anendpoint consumer over the determined displacement length of the jumper.